SA520412495B1 - Treating Seawater for Hydrocarbon Production - Google Patents

Abstract

A system and method for hydraulic fracturing including mixing seawater with an additive to precipitate sulfate from the seawater and mixing a flocculating agent with the seawater to agglomerate the sulfate precipitates. Fig 1.

Description

dallas Treating Seawater for Hydrocarbon Production Full Description Background The present specification relates to hydrocrion production and hydraulic fracturing involving seawater treatment for hydraulic fracturing fluid for hydraulic fracturing Hydraulic fracturing is a process stimulation of wetting through one or more fracturing rock formations 78000760. The process involves pressure injection of fracturing fluid into the wellbore to cause fractures; So that fluids can flow more freely through the rock formation. Hydraulic fracturing can increase the kinetics of the sequestered hydrocriones and thus increase the recovery of the hydrocriones from the reservoir. The fracturing fluid is most commonly formulated with fresh water 0 however; Fresh water can be expensive and difficult to obtain in some production areas. Sea water can decompose produced water; brine; or similar total dissolved solids (TDS) as hydraulic fracturing base fluid in fracturing fluids produced at blasthole temperatures. International Patent No. 087887/2012 describes Bh and an apparatus for water treatment. Methods involve contacting a liquid stream with a source containing inorganic and/or divalent ions and separating the stream into a liquid waste 5 and a fluid containing less sulfur than the stream. The effluent contains more sulfate and more inorganic and/or divalent ions than the stream. The apparatus includes a reaction unit which includes an inlet for the feed fluid and an inlet for the inorganic and/or divalent ions 0178a601. The device may include a separator unit that includes an inlet for the output of the reaction unit and an outlet for the effluent; and an outlet for the fluid that contains less sulfates compared to the feed fluid. 0. The fluid containing less sulphates than the stream can be introduced into a subterranean formation.

General description of the invention

An aspect is a hydraulic fracturing method for a geological formation that involves receiving seawater for fracturing

hydraulic; Seawater has a sulfate concentration of at least 3,000 milligrams per liter (mL).

g/l) 0 The method includes mixing an additive with seawater to precipitate sulfate in seawater ¢ Mixing a flocculant with seawater to agglomerate sulfate deposits in seawater Removing sulfate deposits from seawater

the sea to obtain treated seawater; The fracturing fluid is injected with treated seawater through a borehole

Hydraulically fracture the

geological formation

Another aspect is a hydraulic fracturing method for a geological formation; It includes the formation of a fracturing fluid from

CL 10 sea water shall have a sulfate concentration of at least 3000 mg/L. Formation of the fracturing fluid involves mixing seawater with an additive to form a first mixture to precipitate sulfates from Cad water, mixing the first mixture with a flocculant to form a second mixture to agglomerate the sulfate precipitate, and separating the second mixture from the sulfate precipitate. The method involves transporting a fracturing fluid with the second mixture into a subterranean region.

5 Another aspect also relates to a hydraulic fracturing system that includes a sea water treatment system having a mixing facility to combine the substance J to add with sea cla to precipitate the sulfate in the sea water and to combine the flocculant with sea water to agglomerate the sulfate sediment ¢ sea water treatment system to separate the sulfate sediment sea water to obtain treated sea water. A hydraulic fracturing system includes a pump to inject fracturing fluid with treated seawater through a well bore in a geological formation to hydraulically fracturing the formation.

20 Details of one or more subject applications of this specification are given in the accompanying graphics and description. “Claw” al Whey aspects of the subject matter will be evident from the description; the drawings; and the claims. A brief explanation of the drawings

Figure 1 is a diagram of an example fracturing treatment for a well. Figure 12 is a flowchart of a representative hydraulic fracturing method involving seawater treatment. JSG 2b is a flowchart of a representative hydraulic fracturing method involving sea slo processing. 5 Figure 3 shows sea water treated according to Example 1. Figures 4 and b show sea water treated according to Example 2. Figure 5 shows a plot of viscosity and temperature against time according to Example 2. Figures 16 65 shows sea water treated according to Example 3. Figure 7 shows Seawater treated according to Example 4.

0 Figures 18 and 8b show seawater treated according to Example 5. Detailed Description: Concerns about the depletion of fresh water resources have led to the need to develop ways to use available seawater for various oil field applications. may require hydraulic fracturing; For example; millions of liters of water per treatment; Therefore, alternative sources are sought. Sun is represented

The main issues associated with the use of sea water directly without treatment in the presence of sulfate ions in the fluid. When injected into a vitreous clinSl can react with certain cations present in the rock and brine of the formation to produce scales such as calcium sulfate or cag) where the solid sediment can have damaging effects on the formation. Alternatively, the sulfate introduced to the al can lead to the production of toxic (H2S) hydrogen sulfide.

0 as described in the current disclosure; Sea water can be treated to remove sulfate ions. Laboratory experiments are being carried out to synthesize a compound that can react with sulfates. Then a series of tests are performed with a wide range of reactant concentrations and simulated seawater containing sulfates.

To determine the conditions under which a sulfate compound will precipitate. Various analytical techniques are used to confirm the conformity of the crystallized compound as well as the sulfate concentration remaining in solution after crystallization. The sulfate compound is synthesized over a range of conditions; Including concentration ranges of known seawater compositions. Product crystallization occurs rapidly (ie, in minutes) at high concentrations; While precipitation (Ua) and larger crystals are formed on more dilute conditions. Bde on that; Explain the analysis

elemental residual solution that it is possible for the residual concentration of sulfate to reach trace levels. The subject matter described in this specification can be implemented; To use salt water (such as sea water) instead of fresh water for fracturing fluids. Treated seawater can also have an increased viscosity (longer viscosity and stability life); Where fracturing fluids can enhance. It can too

0 Using sulfate deposits removed from sea water as weighting agents in oil field applications. Figure 1 shows an example of fracture treatment 10 for fracturing 12. All 2 in pit iy 20 could be a problem in the subterranean zone 14 of a geological formation in the Earth's crust. The subterranean region could include 14; For example; formation; part of a composition or multiple formations in a hydrocarbon-laden reservoir from which recovery operations can be exercised to recover hydrocrions

5 withheld. Examples of unconventional reservoirs include gas impermeable sands; coal bed methane; heavy oils and tar sands; deposits of gas hydrates; For example but not limited to. in some applications; The subterranean zone includes 14 underground formations of naturally fractured rocks containing hydrocarbons (eg gaseous oil or both). For example (Jal) the subterranean region can include 14 broken children. In some applications,

0 jul 12 intersects with other suitable types of formations; La including tanks that do not naturally break in any large amount. jill 12 can include well casing 22 and well head 24. Blister bore 20 can be vertical; horizontal; italics or a multi-sided pit. casing al 22 may be cemented or otherwise suitably fixed in blister hole 20. holes 26 can be machined in ll casing 22

5 at subterranean level 14 to allow oil; Gas; and by-products flow into the pustules 12

ag they are produced to the surface 25. Holes 26 can be machined using shape charges; perforating gun; or otherwise. To treat fracturing 10) A worker 30 drill-tube may be placed in all hole 20. A worker 30 drill-tube may be a coiled tubing; a split-tube; or another suitable tubing. A 32 ripper may be coupled to the end of the drill-tubing Agent 30. The gaskets 36 can seal the annulus 38 of the blister hole 20 above the ool and below the ull of the subterranean region 14. The gaskets 36 can be mechanical; Couple one or more pUMP trucks 40 to the working drill string 0 30 at surface 25. The pUMP trucks 40 pump fracturing fluid 58 down the working drill string 30 to perform fracturing treatment 10 to effect fracturing 60. fracturing 60 in rock 75 of an aquifer formation 14. The fracturing fluid 58 can include a soft fluid; support materials; a wash fluid; or a combination of these components. The fracturing fluid 58 can include treated seawater 57; as described below. Pump Trucks 5 40 can include mobile vehicles; “Jie Equipment Crawlers” or other suitable structures. One or more Equipment Trucks 44 can also be provided at deck 25. Equipment Truck 44 can include a fracturing control system 46 and a fracture simulator simulator 47. The fracturing control system 46 monitors the fracturing process control 0. The fracturing control system 46 can control the pump trucks 40 and fluid valves 0 to stop the fracturing processing sag 10) as well as stop and start the phase softball; support material developed; and the washing phase of the fracturing treatment 10. The fracturing control system 46 communicates with surface and subsurface equipment to monitor and control the fracturing treatment 10. In some applications; Surface and subsurface equipment can include surface sensors 48″, down-hole sensors 50″; Pump controls 5 52.

The amount of energy used by the fracturing control system 46 fractures uss 60 in the subterranean region 14 can be affected not only by the properties of the reservoir rocks in the subterranean region, but also by the formation of crusts in the subterranean region where the fracturing fluid components interact fracture fluid 58 with certain components found in rocks.

Chemical additives 81 may be mixed with fracturing fluid 58 and flow through the tank. The fracturing fluid 58 may include treated seawater 57; For example, seawater 102 that has been treated to remove sulfate ions 1005, treated seawater 57 can have less than 2 molar (molar) concentrations of sulfate ions; Less than 0.01 M sulfate ions» Less than 5 M sulfate ions»; or a lower concentration of sulfate ions. For example, it can

0 Treatment of sea water with additives that make sulfate ions precipitate from sea water. Removing sulfate ions from seawater prior to using seawater in the oil field process can help prevent crust formation, thereby reducing subsurface 14 damage and enabling access to large quantities of hydrocriones.

5 on certain models; The fracking treatment 10 includes the ele Bahr treatment system 100 which receives and treats seawater 102 to produce treated seawater 57 as the base fluid in the fracturing fluid 58. The seawater treatment system 100 includes equipment for sedimentation of sulphates and removal of precipitated sulphates from seawater 102. In fact; in operation; A seawater treatment system 100 removes sulfates from seawater 102. In some applications; The receiving seawater 102 does not include scale inhibitors and/or is Ble from seawater

0 is not processed. also; Seawater 102 can contain at least 3,000 milligrams per liter (mg/l) as perbutates; or at least 4,000 Ale sulfate g/L. in operation; The sea ole treatment system 58 mixes an additive 104 with sea water 102 to precipitate sulfate in sea water 102 to produce a sulfate precipitate in sea water 102. The additive may include 104; For example (JU) barium chloride asl is calcium chloride

calcium chloride ¢ barium chloride dihydrate or -calcium chloride dihydrate in these examples; The sulfate sediment particles can be barium sulfate or calcium sulfate sulfate 08100000. The additive stream 104 may include a product fluid to dissolve sale (addition 104) facilitate the transfer and dispersion of sale (addition 104) and so on. In applications The produced fluid can be a product fluid of ll 12 or i neighbors The product fluid in the additive stream 104 can include product water, a brackish water brine, or combinations thereof. That the seawater treatment system 100 sale add flake 106 dale (float) to seawater 102 to flocate or agglomerate the sulfate sediment. Agglomeration of sulfate sediment 0 particles can accelerate sediment settlement and facilitate the separation of sulfate sediments 108 (eg barium sulfate, calcium sulfate, etc.) from seawater 102. Examples of flocculants 106 include polyacrylic compounds cationic amide; anionic and non-ionic copolymers of acrylamides. in some applications; Coagulants may be added with Flocculant 106. Furthermore; where treated seawater 57 is used as fracturing fluid ll 12; 5 sale Flocculant 106 may include a viscosity agent or friction reducer; or both. once again; The sulfate deposits 108 are removed to produce treated seawater 57. In addition to the cell treated seawater 57 can be a viscosifier or friction reducer. Treated seawater 57 may have a lower sulfate concentration than the solubility level of sulfate in treated seawater 57. In certain applications; Treated seawater 57 has less than 200 mg/L 0 sulfates; less than 190 AL g/L; less than 100 AL g/L sulfate; or less than 90 mg/L sulfate. The seawater treatment system can include 100 ciel cali sedimentation tanks”; marketing units; aad means; pumps; tube set controls and the like; For precipitation of sulfates and removal of sulfate deposits from sea water 102. For example; The system may include 5 100 tubes for receiving the produced fluid and for incorporating additive 104 into the produced fluid; and provide fluid

product with addendum 104 to; For example; mixing medium. In reality; The agitator can combine additive 104 with seawater 102 and the flocculant with seawater 2. In one application the agitator is a slog with agitator. Furthermore it; in certain models; The seawater sedimentation vessel 102 provides agglomerated sulphate sediments to move to the bottom of the sedimentation vessel to be removed via an outlet on the lower gall of the sedimentation vessel. maybe

Employ a separation method. in certain applications; The sedimentation vessel is a vessel with a stirrer (to be extinguished) or another vessel. The system may include 100 pumps as a means of driving the flow of treated seawater 57 to pump trucks 40; And so on. An example is a hydraulic fracturing system that includes a seawater treatment system with a mixing medium to combine

0 - An additive with sea water to precipitate sulfate in sea water and to combine the flocculant with sea water to agglomerate the sulfate sediment. in applications; The system treats seawater with a sulfate concentration of at least 3,000 milligrams per liter (mg/l). in particular examples; The receiving seawater shall be untreated seawater or without scale inhibitor. lad The system can be designed to receive a product fluid (eg; product water or brine) to combine the additive with seawater. get up

5 Seawater treatment system by separating sulfate sediments from seawater to produce treated seawater (eg, sulfate concentration <90 mg/L). Furthermore it; The system may incorporate a viscosity agent or friction reducer; or both with a flocculant so that the treated seawater is a viscosity agent or friction reducer; or both. The hydraulic fracturing system includes a pump to inject fracturing fluid with treated seawater through a blister bore in a geological formation to fracturing the formation

0 Geological Hydrolyzed. Figure 12 is a 200 method for treating sea water. at 201; Seawater and an additive are mixed to form a first mixture. When mixed with seawater, the additive sale causes precipitation of sulfates from the seawater. The additive may include product water; Brine; brackish water; or combinations thereof. The additive may include hydrate; divalent cations or combinations thereof.

5 for example; The additive can be a brine containing ions

Dissolved barium or calcium ions, sale The addition can be Jia ¢ hydrate barium chloride dihydrate or calcium chloride dihydrate The water produced is Ble water that occurs naturally in a rock (eg formation water) or water trapped in a rock during formation (eg locked water); which can be produced from a well. in some applications; The seawater used in 201 is untreated seawater. Untreated seawater is seawater that has not been substantially treated or treated to alter its chemical properties or to remove contaminants from the seawater between the moment the seawater is obtained and the moment the seawater is used. the term “substantially” as used in the present disclosure denotes a majority; or most; As in at least 0 about 50 percent (%)” or at least about 9080 3670 37090 37095 3096 3697 906968 9 9699.5 9699.9 9699.99 or at least about 9 or more. In some applications, the seawater used in dallas 201 is already (Jha) for removing pollutants from seawater. In some applications, seawater does not include a scale inhibitor. A scale inhibitor is any component that may be added to a fluid to delay or prevent scale settling on equipment or piping. Some examples of scale inhibitors are acrylic acid polymers maleic acid polymers and phosphate compounds In some applications the salt is dissolved in the first mixture to increase the hydrogen potential (pH) of the first mixture The pH can be for the first mixture between 7 and 9. For example, sodium bicarbonate 3 may be dissolved in the first mixture to increase 0 to the pH of the first mixture to approximately 7. The term “approximately” as used in the present disclosure indicates a deviation or tolerance of up to 9610. At 203; the first mixture is mixed with a flocculant to form a second mixture. The flocculant precipitates the sulfates into agglomerates. The agglomeration of the sulfate sediment particles can accelerate the sedimentation of the sediment and facilitate the separation of the sediment from the second mixture. The flocculant may include a 5 viscosity agent (any suitable component that increases the viscosity of the fluid) and a friction reducer (any suitable component that alters

The rheological properties of a fluid in such a way that the friction that occurs in the fluid is minimized as the fluid flows through the constraints). The flocculant may include a polymer; copolymer Jie hydrate, aluminum sulfate hydrate; or combinations thereof. Examples of suitable flocculants include cationic polyacrylamides;

anionic and non-ionic 8010016 and 0 acrylamide copolymers in some applications; Clotting agents can be used in combination with flocculants 896015 0000018109 eg; A clotting agent that includes aluminum compounds or wall 1200 can also be used with flocculant 1000018109 1. The second mixture may have a sulfate concentration lower than the solubility level of sulfates in the mixture

0 second. in certain applications; The sulfate precipitates are separated from the second mixture. The second mixture with less or reduced sulphate sediment (i.e., the sulfate precipitate is separated from the second mixture) may be used as fracturing fluid or as base fluid for fracturing fluid in 205; The fracturing fluid (eg JU) is transported through a borehole (Uh) to a subterranean region in a geological formation for geological hydraulic fracturing of the subterranean zone. eg Jal) The fracturing fluid can be pumped down

5 the well to the subterranean region. The fracturing fluid may also be optionally treated prior to transporting the fracturing fluid to the subsurface. An example is a method for the hydraulic fracturing of a geological formation; It involves forming a fracturing fluid from seawater having a sulfate concentration of at least 3,000 milligrams per liter (mg/L). Formation of the fracturing fluid includes: mixing seawater with an additive to form a Jf mixture to precipitate the sulfates from

ole 0 sea; mixing the first mixture with a flocculant to form a second mixture to agglomerate the sulfate precipitate; The second mixture was separated from the sulfate precipitate. The method involves transporting a fracturing fluid with the second mixture into a subterranean region. in some applications; Seawater does not include a scale inhibitor. in certain applications; Sea water is untreated sea water. The formation of the fracturing fluid may involve dissolving a salt in the first mixture; The salt is designed to increase the hydrogen potential (pH) of the first mixture. V.V

5 specific applications; The pH of the first mixture is between 7 and 9. in applications; Bale

— 2 1 — Addition to precipitate crystalline sulfates. The additive sale can be a hydrate ; A divalent cation, or combinations thereof. In the carne application the hydrate is barium chloride dihydrate (gla «chloride dihydrate] calcium chloride dihydrate or combinations thereof. sale addition can include product water; brine; striking water to salinity; or combinations thereof Gall agent can be an aly copolymer aluminum sulfate hydrate or combinations thereof Flocculant agent 1000013100 can include a viscosifier or friction reducer ¢ or combinations thereof.

0 Figure 2b is a method 210 of hydraulic fracturing of a crustal geological formation. In 2. The method involves taking sea water. Seawater can have a sulfate concentration of at least 0 mg/L. Ble seawater can be untreated or unflavored seawater, or a combination thereof. in certain models; Untreated seawater is received at the Ji site where hydraulic fracturing takes place.

In 14 the method includes mixing an additive with sea water to precipitate the sulfate in the sea water. The addition sale can include or be “for example” barium chloride sha calcium chloride barium chloride hydrate

“dihydrate” or “calcium chloride dihydrate” or any combination thereof.

0 In that dil the sulfate deposit is barium sulfate, calcium sulfate, or a combination thereof. Ble In addition, the additive can include a product fluid (eg; ( File ele = brine; =( from a blister. For example » additive may be added to the fluid produced and the additive/product fluid stream added to seawater.

in 216; The method involves mixing a flocculant or flocculant with seawater to agglomerate the sulfate deposits in the seawater. The flocculant stream added to seawater may include a viscous agent or friction reducer; or both where the treated seawater includes a viscosity agent or a friction reducer. In reality; The amount of viscosity agent or friction reducer in the flocculant may be determined in light of the seawater treated as fracturing fluid or fracturing fluid component. In Box 218 the method involves removing sulfate deposits from seawater to obtain treated seawater. In one application the agglomerated sulfate deposits are deposited by sale flocculant at the bottom of the vessel for removal. In another application an eo separator is employed. For example » centrifugal separation device; Fluid Separators etc.) to remove agglomerated sulphate deposits from seawater 0 to obtain treated seawater. in a specific form; Treated seawater has a sulfate concentration of less than 0 mg/L. in frame 220; The method involves injecting a fracturing fluid with treated seawater through a blistering bore in a geological formation to hydraulically fracturing the geological formation. The fracturing fluid may include chemical additives. The fracturing fluid may also include a support material such as sand or other types of support material 5. The fracturing fluid can be injected into the geological formation by means of multiple pumps. An example is a hydraulic fracturing method for a geological formation; It involves receiving seawater for hydraulic fracturing and mixing the additive with seawater to precipitate the sulfate in the seawater. in applications; Sea water can be received at the well site and the additive can be mixed with sea water at the well site. The receiving seawater can have a sulfate concentration of at least 3000 mg/L 0 sulfate concentration. The receiving seawater can be untreated seawater or have no scales. sale of the additive may include barium chloride calcium chloride barium chloride dihydrate or calcium chloride dihydrate or any combination of terminators and where the sulfate precipitate is sulfate barium sulfate, calcium sulfate 25, or a combination thereof. The additive may include a fluid produced from a blister. method includes

— 1 4 — Mixing a flocculant with seawater (to agglomerate sulfate deposits in seawater) and remove sulfate deposits from seawater to produce treated seawater. in an application; The treated seawater has a sulfate concentration of less than 90 (Ae) g/l. The flocculant agent may include a viscosifier, a lial, or both; and where the treated seawater includes a viscosifier or a friction reducer; or both, by Flocculant Agent The method involves drilling a fracturing fluid with treated seawater through bore i at the well site in a geological formation to hydraulically fracturing the geological formation Table 1 shows a composition for an example of untreated seawater The components listed in Table 1 can be present in water Untreated sea as items that contain the aforementioned components. For example (Jal) boron can be found in untreated sea water as boric acid 8600 and 0 calcium can be found in untreated sea water as dissolved ions or an inorganic compound Contains calcium as calcium sulfate. Ingredient/Characteristic Concentration/Value Calcium 8 mg/L Magnesium 8 mg/L Potassium 5 mg/L Strontium 11 mg/litre

Total dissolved solids 0 mg/L

Table 1 Table 2 shows an example composition of treated seawater. The components listed in Table 2 may be present in treated seawater as items containing the said component. For example, barium can be present in the produced water as Lie 015501780 ions.

— 6 1 — Total hardness 0 mg/L Table 2 In the following examples; Untreated seawater and produced water have the characteristics given in Tables 251, respectively. Example 1

An aqueous solution with a concentration of approximately 39.9 kilograms per thousand liters, which is approximately 0.12 grams per liter, barium chloride dihydrate, is added to the untreated seawater during mixing; So that the sulfates are found in the untreated sea water precipitated as barium sulfate as one of the dial) 1.053 (an) aba barium chloride hydrate is added

chloride dihydrate to the mixing medium; dang that untreated seawater is added to the 0 mixing medium until the final volume is 100 milliliters (ml). Barium chloride dihydrate dissolves quickly in sea water and in the form of a solution containing barium sulfate particles. The solution (i.e. treated seawater) is poured into a 100 mL graduated cylinder (do) and left; Figure 3 shows the precipitation of barium sulfate in treated seawater after 10 minutes from ald to the 100 mL graduated cylinder.

As shown in Figure 3, the treated seawater still appears cloudy; Where it can be interpreted as meaning that the solution requires more time for sedimentation. Example 2 A solution is prepared by dissolving barium chloride hydrate in untreated seawater while mixing (vie) 5 ratio of 1.053 g of barium chloride hydrate per Ale TOO liter of final fluid; which is a concentration of approximately 39.9 per thousand liters); So that sulfates are found in untreated sea water precipitated as barium sulfate. Barium chloride hydrate dissolves quickly in sea water and forms a solution that contains particles such as barium sulfate. Then Bribie flocculant is added during mixing (for a resulting concentration of approximately 0.3 kg of flocculant per thousand liters). In the current example; 0 The flocculant is HE® 150 Polymer from Drilling Specialties Company LLC The solution (i.e. treated seawater) is poured into a 100 Ale graduated cylinder and left so that a precipitate of 88504 can precipitate. Figure 4 The treated seawater after 1 minute was transferred to the 100 mL graduated cylinder. Figure 4 shows the treated seawater 10 minutes after it was transferred to the 100 mL graduated cylinder. The activity of the flocculant in precipitating sulfates in untreated seawater can be determined by optical anil or by turbidity (ie, measurement of solution clarity). The treated seawater is then separated from the flocculent sediment (which was deposited at the bottom of a 100 mL inserted cylinder). Calcium chloride is added to treated seawater to form a brine with a salt concentration of approximately 30% by weight (96). Sale Erucamidopropyl hydroxypropylsultaine (VES) viscoelastic surfactant is added to the brine at a volume ratio of approximately 965 (ie, the volume of VES added to the volume of the brine). In the current example; VES is Armovis® EHS from Akzo Nobel Surface Chemistry LLC. Brine with VES is also referred to as base fluid. The base fluid is heated to 5°C (approximately 176.6°F) to simulate subterranean conditions. The viscosity of the base fluid is measured with a scale

viscosity Follows American Petroleum Institute Recommended Practice Table 39 (39) API RP The viscosity and temperature of the base fluid are recorded and represented by curve 508 and dashed curve 512; respectively; in Figure 5. The left y-axis 502 is viscosity The measured fluid is kilograms per meter-seconds The right y-axis 510 is the temperature of the fluid measured in Fahrenheit The x-axis 504 is the time since the beginning of the measurements in minutes and with time = almost zero when the heating starts Another base fluid is prepared but the Addition of additional flocculant The flocculant is added to the base fluid during mixing (for a yield concentration of approximately 35.8 kg flocculant per thousand liters) The base fluid is heated with additional flocculant to a temperature of approximately 176.6° 0 s Sal Conditions Underground viscosity of the base fluid with additional flocculant is measured with a viscometer; follows API 39 RP The viscosity of the base fluid with additional flocculant is recorded and is represented by Curve 506 in Figure 5. As shown in Figure 5, the flocculant exhibits both synergistic and functional properties Double with treated seawater and enhances the viscosity of treated seawater. The direct use of flocculant is the rapid precipitation of sulfate in seawater as 88504; But Flocculant 5 also acts as a viscosity enhancing agent (as shown in Figure 5). The fluid (base fluid with flocculant) is also compared with a comparator solution of seawater and flocculant (absence of VES). The comparator solution exhibits a viscosity J of 20cP at 350"F. In the comparison, synergy of VES and flocculant is shown. Flocculant in enhancing the viscosity of the fluid in Figure 5 (Curve 506). Figure 5 is a graph of 500 Viscosity 502 and temperature decimal point 510 over time (min) 504. Curve 508 is the viscosity of the base fluid Curve 506 is the viscosity Base fluid with the additive of an additional amount of flocculant Curve 2 is the temperature of the base fluid Example 3 A solution is prepared by dissolving barium chloride dihydrate in untreated seawater during mixing 5 (at a ratio of 1.053 g of barium chloride dihydrate per 100 Me liters of final fluid;

which is a concentration of approximately 39.9 kilograms per thousand liters); So that sulfates are found in untreated sea water precipitated as barium sulfate. Barium chloride dihydrate dissolves rapidly in Al water forming a solution containing barium sulfate particles. immediately thereafter; A partially hydrolyzed polyacrylamide tertiary polymer is added as a solid (dale) flocculant.

During mixing to a yield concentration of approximately 0.3 kg of flocculant per thousand liters. The solution (i.e., treated seawater) is poured into a 100 Ale liter graduated cylinder and left; So that the sediment of 88504 can precipitate. Figure 16 shows the treated seawater after 1 minute of transfer to the 100 mL graduated cylinder. Figure 6b shows treated seawater 10 minutes after it was transferred to the 100 mL graduated cylinder.

Example 4 A solution is prepared by dissolving barium chloride dihydrate in untreated seawater during mixing (ie a ratio of 1.053 grams of barium chloride dihydrate per 100 Me liters of final fluid); which is a concentration of approximately 39.9 kilograms per thousand liters); So that sulfates are found in untreated sea water precipitated as barium sulfate. Barium chloride dihydrate dissolves rapidly in seawater 5 forming a solution containing barium sulfate particles. immediately thereafter; Solid sodium bicarbonate is added during mixing (for a resulting concentration of approximately 36 kg of solid sodium bicarbonate per thousand liters); This results in a pH of approximately 7.3. immediately thereafter; Aluminum sulfate is added during mixing at a ratio of 2 parts additive per gga call total solution (parts per thousand by volume). 0 Aluminum sulfate additive is prepared by adding 20 g aluminum sulfate hydrate to water; With a final pas of 100 Me liters. The solution (i.e., treated seawater) is poured into a 100 mL graduated cylinder and left; So that barium sulfate precipitates can precipitate. Figure 7 shows the treated seawater 10 minutes after it was transferred to the 100 mL graduated cylinder.

The treated seawater is then separated from the flocculent sediment (which was deposited at the bottom of the graduated cylinder

0 milliliters). Calcium chloride is added to the treated seawater to form a concentrated brine

Salt is approximately 30 percent by weight (96). Irocamidopropyl hydroxypropyl sulfate is added

(VES) Erucamidopropyl hydroxypropylsultaine to brine at a volume ratio of

5 approximately 965 (ie, the volume of VES added to the volume of the brine). The brine is heated

with VES to a temperature of approximately 350" Fahrenheit to simulate subterranean conditions. The fluid viscosity is measured

basic with a viscometer; Follows the American Petroleum Institute's recommended practice schedule of 39

(API RP 39).

Example 5

10 A solution is prepared by dissolving calcium chloride dihydrate in untreated seawater while mixing vie (concentration approximately 163.2 kg per thousand liters); So that sulfates are found in untreated sea water precipitated as barium sulfate. Calcium chloride dihydrate dissolves rapidly in gall water forming a solution containing calcium chloride particles. Then (Bilas) a flocculant is added during mixing (for a resulting concentration of approximately 0.3 kg of flocculant).

5 per thousand liters). The solution in gl (treated seawater) is poured into a 100 mL graduated cylinder dling so that a calcium sulfate precipitate can precipitate. Figure 18 shows the treated seawater 0 minutes after it was transferred to the 100 mL graduated cylinder. Figure 8b shows treated seawater after 1 hour from ald to a 100 Ale liter graduated cylinder. The treated seawater is then separated from the flocculent sediment (which was deposited at the bottom of the graduated cylinder

0 100 mL). 08012 is added to treated seawater to form a brine with a salt concentration of approximately 30% by weight (96). Errucamidopropyl hydroxypropyl sulfate (VES) is added to the brine at a volume ratio of approximately 965 (ie, the volume of VES added to the volume of the brine). In the current example; VES is Armovis® EHS from Akzo Nobel Surface Chemistry LLC. The brine with VES is heated to

Temperature approximately 350"F to simulate subterranean conditions. Base fluid viscosity measured with a viscometer; follows American Petroleum Institute Recommended Practice Table 39 (39) API RP The present disclosure describes techniques related to hydrocrion production including sea water. An application is Representative of the subject matter described in the present disclosure in a method involving mixing seawater with an additive to form a first mixture and mixing the first mixture with a flocculant to form a second mixture; in which the additive may precipitate the sulphates from the seawater and the flocculant may agglomerate the sulphate precipitate Aspects of representative application that may be combined with representative application alone or in combination cae include the following Method may include separation of second mixture from sulfate precipitation Sale addition can precipitate crystalline sulfate Seawater may include water Untreated sea The sea water does not include a scale inhibitor The flocculant agent may include a polymer; a copolymer; aluminum sulfate hydrate ¢ or combinations thereof The flocculant may include a viscosity agent; a friction reducer; or combinations thereof Bale additive can include produced water; Brine; brackish water; or combinations thereof. sale can include the addition hydrate; A divalent cation or combinations of both. The hydrate 5 can be barium chloride dihydrate; calcium chloride dihydrate, or combinations of both. The method could involve dissolving salt in the first mixture; in which the salt can increase the hydrogen potential (pH) of the first mixture. The pH of the first mixture can be between 7 and 9. Another exemplary application of the subject matter described in the present disclosure is a method involving the formation of a fracturing fluid 0 from seawater in which the formation of the fracturing fluid involves mixing seawater with an additive to form a mixture Jf and mixing the first mixture with a flocculant to form a second mixture; As the sulfate additive can precipitate from “yall” water and the flocculant can agglomerate the sulfate precipitate; The fracturing fluid was transported to a subterranean area. Aspects of the representative application include; which may be combined with the analog application alone or in combination; the following. The method could involve separating the second mixture from 5 sulfate deposits. The flocculant may include a viscous agent; friction reducer or combinations

from both. The additive may include product water; Brine; brackish water; or combinations thereof. The method could involve dissolving salt in the first mixture; in which the salt can increase the pH of the first mixture. The pH of the first mixture can be between 7 and 95. The additive can include hydrates; ESE, or combinations of both. The hydrate can be barium chloride dihydrate

; calcium chloride dihydrate, or combinations thereof. Lay The current specification contains specific application details; They are not to be construed as limitations on the subject area or on the area of what may be protected; Rather, it is a description of features that may be specific to specific applications. Certain features that are described in this specification can also be applied to

separate applications context; in combination in one application. On Sal (Lad) different attributes that are described in the context of a single application can be applied in multiple applications; separately; or in any discrete sub-combination. Furthermore, although the previously described attributes can be described as operating in combinations Even in dls, it is initially protected in this way; in some applications, one or more of the code attributes that are protected from the code can be dispensed with.

5 The combination being protected can be directed to a sub-module or a variant of the sub-module. Specific applications of the topic are described. be applications; substitutions and other permutations of the applications described within the scope of the following claims as will be construed to those skilful in the art. While operations are shown in drawings or safeguards in a specific order; This is not to be understood as requiring shal to perform such operations in a particular order shown or in sequential order” or for shal to be executed

0 All operations described (Sa (Some operations are optional); to achieve desired results. Subsequently; The previously described representative applications do not limit or limit the current detection. be changes; substitutions Other alterations are also possible without deviating from the content and scope of the current disclosure.

Claims (1)

Protection Elements 1- Hydraulic fracturing method _ for a geological formation that includes: receiving sea water for hydraulic fracturing; Seawater has a sulfate concentration > 3000 milligrams per liter (mg/L); Mixing an additive with sea water to precipitate the sulfate sea water; Mixing flocculant agent 100001809 with seawater to agglomerate sulfate deposits in seawater where the flocculating agent includes a viscosifier or a friction reducer »or both; removal of sulfate deposits from seawater to obtain treated seawater; where the treated sea slo 0 includes a viscosifier, a viscosifier, a friction reducer, or both. by flocculant agent 1000018109; And injecting a fracturing fluid that includes treated seawater through a well bore in the geological formation _ to hydraulically fracture the geological formation. 2 - method for claim 1) wherein the treated seawater includes a sulfate concentration >90 mg/l. 3 - method for claim 1; Gus seawater reception includes seawater reception at 0 cutting site It includes a septic hole and where the mixing of the additive with seawater involves mixing the Bale additive with seawater at the well site 4- The method according to claim 1, where the seawater includes untreated seawater. 5. The method according to claim 1; Where sea water does not contain a scale inhibitor. 6- The method according to claim 1 where the additive includes barium chloride 5 6 M calcium chloride; (gla) barium chloride hydrate 581100177 “chloride dihydrate or calcium chloride dihydrate” or any terminated combinations and where the sulfate deposit includes barium sulfate 508 or calcium sulfate sulfate 01000L8 0 7- The method according to claim 1, where the additive includes a fluid produced from a well 8- A hydraulic fracturing method _for a geological formation that includes: formation of a fracturing fluid from seawater Seawater includes a sulfate concentration of > 3000 milligrams per liter (mg/L); where seawater does not include a scale inhibitor and where the formation includes: mixing seawater with an additive to form a first mixture to precipitate sulfates 501816 from seawater; mixing the first mixture with flocculant agent 1000018809 to form a second mixture to agglomerate sulfate deposits where flocculant agent 1000018109 includes a viscosifier | 0 or a friction reducer or combinations thereof, and separating the second mixture from the sulfate deposits; and transferring a fracturing fluid comprising the second mixture to a subterranean zone. 9- The method according to claim 8; Where the additive is designed to precipitate 5-crystalline sulfates; Whereas, the flocculating agent includes — 5 2 — polymer ‎; copolymer; aluminum sulfate hydrate (216 A50); or combinations thereof. 0 - the method according to claim 8; Where sea water includes untreated sea water; Whereas, the additive includes product water; Brine; brackish water; or combinations thereof. 1. The method in accordance with claim 8; Gus The sale add-on includes hydrate ; divalent cation or combinations thereof. 0 12- Method according to claim 11) where the hydrate is barium chloride dihydrate; sha calcium chloride dihydrate or combinations thereof. 3- Method according to claim 8; where Formation also involves dissolving a salt in the first mixture 5; the salt is designed to increase the hydrogen potential (pH) of the first mixture. and 9. 15- Hydraulic fracturing system comprising: a seawater treatment system comprising a mixing device to combine an additive with seawater comprising untreated seawater to precipitate the sulfate in the seawater and to incorporate a flocculating agent comprising viscosifier or friction reducer; or both with seawater to agglomerate sulfate deposits; Seawater treatment system 5 to separate sulfate deposits from seawater to obtain treated seawater that includes a viscosifier or a friction reducer ; or both; And — 6 2 — A pump for injecting a fracturing fluid comprising treated seawater through a borehole in a geological formation to hydraulically fracture the geological formation 5 16- The system according to claim 15 where the seawater contains a sulfate concentration sulfate > 0 milligrams per liter (mg/L); and wherein the additive includes a fluid produced from LR 7 - the system of claim 15; Where sea water does not contain a scale inhibitor; Whereas, the treated seawater has a sulfate concentration >90 mL 0 g/L. 8- The method of hydraulic fracturing sign ne for a geological formation includes: receiving sea water for hydraulic fracturing; Sea water contains concentrate sulfate > 3,000 milligrams per liter (mg/L); Mixing an additive with sea water to precipitate sulfate in sea water ¢ dala flocculant agent 1000018109 with sea water to agglomerate sulfate deposits in sea water ¢ Removing sulfate deposits SU Ifate from sea water to obtain water medicated sea; And 0 Injection of a fracturing fluid comprising treated seawater through a bore hole in the geological formation to hydraulically fracture the geological formation. 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A 0 = A 0 A A 0 - A 0 0 A L 0 1 101 + + A La Dal NN SL Lo 7 0 a ve LER and 4 i peed r = TA Tee ee 3 0 Ne Mal et Fig. ha 0 0 x a H- i to 7" (Bm Wa ¥ y Fig. -4 3 — 3 i 1 cl a y Ae | 3 Js | 0 0 a 1 a a a : º ne: i 1 0 0 l “1 1 0 0 - | 1 a s As ' 8 0 1 IA : a 0 . a a — : a a 0 l l l 08 ahm z 0 = ; = : a b figure b 1 l =f b 07 = - 0 7 figure 12339 The Saudi Authority for Intellectual Property Sweden Authority for Intellectual Property pW RE .¥ + \ A 0 § Um 5 + < Ne ge “Benaj > Aye Ki Jada Li Days TEE Bbha Nase eg + Ed - 2 - 3 .++ .* provided that the annual financial fee is paid for the patent and that it is not null and void due to its violation of any of the provisions of the patent system, layout designs of integrated circuits, plant varieties and industrial designs or its implementing regulations. »> Issued by + BB 0.B Saudi Authority for Intellectual Property > > > “+ PO Box 1011 .| for ria 1*1 uo ; Kingdom | Arabic | For Saudi Arabia, SAIP@SAIP.GOV.SA